CA2708922A1 - Optimized reaming system based upon weight on tool - Google Patents
Optimized reaming system based upon weight on tool Download PDFInfo
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- CA2708922A1 CA2708922A1 CA2708922A CA2708922A CA2708922A1 CA 2708922 A1 CA2708922 A1 CA 2708922A1 CA 2708922 A CA2708922 A CA 2708922A CA 2708922 A CA2708922 A CA 2708922A CA 2708922 A1 CA2708922 A1 CA 2708922A1
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- cutter blocks
- activation
- drilling apparatus
- primary
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- 230000004913 activation Effects 0.000 claims abstract description 79
- 238000005553 drilling Methods 0.000 claims abstract description 73
- 230000004044 response Effects 0.000 claims abstract description 3
- 239000012530 fluid Substances 0.000 claims description 25
- 238000000034 method Methods 0.000 claims description 17
- 230000003213 activating effect Effects 0.000 claims description 2
- 230000015572 biosynthetic process Effects 0.000 description 18
- 238000005755 formation reaction Methods 0.000 description 18
- 230000003247 decreasing effect Effects 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- 230000035515 penetration Effects 0.000 description 3
- 230000002028 premature Effects 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 239000003381 stabilizer Substances 0.000 description 2
- 241001481828 Glyptocephalus cynoglossus Species 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000001627 detrimental effect Effects 0.000 description 1
- JEIPFZHSYJVQDO-UHFFFAOYSA-N ferric oxide Chemical compound O=[Fe]O[Fe]=O JEIPFZHSYJVQDO-UHFFFAOYSA-N 0.000 description 1
- 238000013507 mapping Methods 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/28—Enlarging drilled holes, e.g. by counterboring
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/26—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/26—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
- E21B10/32—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/26—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
- E21B10/32—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
- E21B10/322—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools cutter shifted by fluid pressure
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- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Earth Drilling (AREA)
Abstract
A drilling apparatus includes a tubular body including an upper connection and a lower connection with a drill bit disposed thereon, and an axial borehole therethrough, wherein the upper connection is configured to attach to a drillstring, primary cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom. The drilling apparatus further includes backup cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom, and an activation system configured to selectively expand and collapse the primary and backup cutter blocks in response to changes in weight applied to the primary ,and backup cutter blocks.
Description
OPTIMIZED REAMING SYSTEM BASED UPON WEIGHT ON TOOL
BACKGROUND
Related Applications [0001] This application is a continuation-in-part of U.S. Application No.
12/170,158, filed July 9, 2008, which is incorporated by reference in its entirety.
Field of the Disclosure
BACKGROUND
Related Applications [0001] This application is a continuation-in-part of U.S. Application No.
12/170,158, filed July 9, 2008, which is incorporated by reference in its entirety.
Field of the Disclosure
[0002] Embodiments disclosed herein relate generally to an activation system for a drilling apparatus. In particular, embodiments disclosed herein relate to an activation mechanism of a drilling apparatus to selectively open and close multiple cutter blocks of the drilling apparatus.
Background Art
Background Art
[0003] In the drilling of oil and gas wells, concentric casing strings may be installed and cemented in the borehole as drilling progresses to increasing depths. Each new casing string is supported within the previously installed casing string, thereby limiting the annular area available for the cementing operation. Further, as successively smaller diameter casing strings are suspended, the flow area for the production of oil and gas may be reduced. Therefore, to increase the annular space for the cementing operation, and to increase the production flow area, it may be desirable to enlarge the borehole below the terminal end of the previously cased borehole. In "hole enlargement while drilling"
operations ("HEWD"), the borehole is enlarged to provide a larger annular area for subsequently installing and cementing a larger casing string. Accordingly, by enlarging the borehole below the previously cased borehole, the bottom of the formation may be reached with comparatively larger diameter casing, thereby providing more flow area for the production of oil and gas.
operations ("HEWD"), the borehole is enlarged to provide a larger annular area for subsequently installing and cementing a larger casing string. Accordingly, by enlarging the borehole below the previously cased borehole, the bottom of the formation may be reached with comparatively larger diameter casing, thereby providing more flow area for the production of oil and gas.
[0004] Various methods have been devised for passing a drilling assembly, either through a cased borehole or in conjunction with expandable casing to enlarge the borehole. One such method involves the use of expandable cutter blocks, which has basically two operative states. A closed or collapsed state may be configured where the diameter of the tool is sufficiently small to allow the tool to pass through the existing cased borehole, while an open or partly expanded state may be configured where one or more arms with cutters on the ends thereof extend from the body of the tool.
In the latter position, the cutter blocks enlarge the borehole diameter as the tool is rotated and lowered in the borehole. During HEWD operations, depending upon operational requirements of the drilling assembly, cutter blocks may be extended or retracted while the assembly is downhole.
In the latter position, the cutter blocks enlarge the borehole diameter as the tool is rotated and lowered in the borehole. During HEWD operations, depending upon operational requirements of the drilling assembly, cutter blocks may be extended or retracted while the assembly is downhole.
[0005] Movement of the cutter blocks typically involves manipulating a sleeve that is used to open or close ports to allow fluid to activate and expand the cutter blocks. In certain prior art applications, the sleeve is held in place with shear pins, and a ball drop device may be used to shear the pins by increasing pressure in the tool to move the sleeve and open the cutter block activation ports. However, once the pins are sheared, the tool stays open for the duration of the drilling interval as long as there is pressure in the tool bore. Therefore, such a configuration may only allow one open cycle. This is also applicable to other tools which may be expanded, including but not limited to, cutting tools, spearing tools, and expandable stabilizers.
[00061 In HEWD operations, the weight on the cutter blocks and the weight on the drill bit may vary depending upon the type of formation in which the bit and cutter blocks are in at any given time. For example, because the cutter blocks may be located up to 60 feet away from the distal end of the drillstring (upon which the drill bit is attached), the drill bit may be in a softer formation while the cutter blocks are in a harder formation. In this case, the cutter blocks may carry excessive amounts of weight, which may cause cutters on the cutter blocks to wear prematurely. As a result, the rate of penetration through the formation slows down. Currently, warning information may be provided to the operator prior to the drilling operation showing particular intervals in the formation that have an increased hardness. This requires preliminary well information to be obtained prior to the drilling operation. From this information, the operator then knows to pass through that interval with care and ease up on the weight on the reamer in order to not wear the cutter blocks prematurely.
[0007] Accordingly, there exists a need for an apparatus and method to compensate for differences in weight on the drill bit and cutter blocks to prevent premature wear of the cutter blocks while maintaining a normal and adequate rate of penetration ("ROP") through the formation.
SUMMARY OF THE DISCLOSURE
[0008] In one aspect, embodiments disclosed herein relate to a drilling apparatus including a tubular body including an upper connection and a lower connection with a drill bit disposed thereon, and an axial borehole therethrough, wherein the upper connection is configured to attach to a drillstring, primary cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom, backup cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom, and an activation system configured to selectively expand and collapse the primary and backup cutter blocks in response to changes in weight applied to the primary and backup cutter blocks.
[0009] In other aspects, embodiments disclosed herein relate to a method of selectively activating cutter blocks in a drilling apparatus, wherein the drilling apparatus includes a tubular body with an axial borehole therethrough, the method including actuating an activation system, providing fluid communication through an activation port in a main sleeve to a primary cutter block activation port and expanding primary cutter blocks, detecting an increased weight applied to the primary cutter blocks, operating the main sleeve to provide fluid communication to a backup cutter block activation port and expand backup cutter blocks when an increased weight is detected on the primary cutter blocks, and collapsing the primary cutter blocks.
[0010] Other aspects and advantages of the invention will be apparent from the following description and the appended claims.
BRIEF DESCRIPTION OF DRAWINGS
[0011] Figure 1A is a cross-section view of a drilling apparatus in accordance with embodiments of the present disclosure.
[0012] Figure 1B is a cross-section view of components of an activation system in the drilling apparatus in accordance with embodiments of the present disclosure.
[0013] Figure 2A is a cross-section view of a main sleeve of the activation system in the drilling apparatus in a run-in hole condition with primary and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0014] Figure 2B is a cross-section view of the drilling apparatus in a run-in hole condition in accordance with embodiments of the present disclosure.
[0015] Figure 3A is a cross-section view of a main sleeve of the activation system in the drilling apparatus with primary cutter blocks expanded and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0016] Figure 3B is a cross-section view of the drilling apparatus with the primary cutter blocks expanded and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0017] Figure 3C is an operation sequence of the activation system shown in Figure 3A
in accordance with embodiments of the present disclosure.
[0018] Figure 4A is a cross-section view of a main sleeve of the activation system in the drilling apparatus with backup cutter blocks expanded and primary cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0019] Figure 4B is a cross-section view of the drilling apparatus with the backup cutter blocks expanded and primary cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0020] Figure 4C is an operation sequence of the activation system shown in Figure 4A
in accordance with embodiments of the present disclosure.
[0021] Figure 5A is a cross-section view of a main sleeve of the activation system in the drilling apparatus with primary cutter blocks returned to an expanded position and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[00221 Figure 5B is a cross-section view of the drilling apparatus with the primary cutter blocks returned to an expanded position and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[00231 Figure 5C is an operation sequence of the activation system shown in Figure 5A
in accordance with embodiments of the present disclosure.
DETAILED DESCRIPTION
[00241 In one aspect, embodiments disclosed herein relate to an activation system and related methods used in a drilling apparatus to selectively open and close expandable cutter blocks of the drilling apparatus. In particular, embodiments disclosed herein relate to methods and apparatus capable of selectively actuating primary and backup cutter blocks during downhole borehole enlarging operations.
[00251 Referring to Figure 1 A, a cross-section view of a drilling apparatus 100 is shown in accordance with embodiments of the present disclosure.j Drilling apparatus includes a drillstring 110 having a drill bit 120 disposed on an ICnd thereof, which drills a pilot hole 111. Drilling apparatus 100 further includes primary cutter blocks 130 and backup cutter blocks 132, which are configured to drill an enlarged borehole 112 along the same path as the pilot hole 111. The cutter blocks are well known in the art and typically include cutting elements and a stabilizer pad (not sown). The primary and ~
backup cutter blocks are configured to travel along grooves (riot shown) formed in the body of the drilling apparatus 100 when expanded or collapsed.]
[00261 The backup cutter blocks 132 may be constructed to'be heavier duty than the primary cutter blocks 130 to withstand cutting in harder formations, and thereby handle more weight. In particular, the backup cutter blocks may be m~re robust by adding extra rows of cutters, using larger size cutters, using more robust cutting materials, varying the cutter shape, or other methods known to those skilled in thei art. Further, the backup cutter blocks may be devoid of cutters for "backreaming," or uiiderreaming while pulling the drilling apparatus out of the wellbore. As such, the backups cutter blocks 132 may be smaller than the primary cutter blocks 130. Embodiments of th'e present disclosure relate
[00061 In HEWD operations, the weight on the cutter blocks and the weight on the drill bit may vary depending upon the type of formation in which the bit and cutter blocks are in at any given time. For example, because the cutter blocks may be located up to 60 feet away from the distal end of the drillstring (upon which the drill bit is attached), the drill bit may be in a softer formation while the cutter blocks are in a harder formation. In this case, the cutter blocks may carry excessive amounts of weight, which may cause cutters on the cutter blocks to wear prematurely. As a result, the rate of penetration through the formation slows down. Currently, warning information may be provided to the operator prior to the drilling operation showing particular intervals in the formation that have an increased hardness. This requires preliminary well information to be obtained prior to the drilling operation. From this information, the operator then knows to pass through that interval with care and ease up on the weight on the reamer in order to not wear the cutter blocks prematurely.
[0007] Accordingly, there exists a need for an apparatus and method to compensate for differences in weight on the drill bit and cutter blocks to prevent premature wear of the cutter blocks while maintaining a normal and adequate rate of penetration ("ROP") through the formation.
SUMMARY OF THE DISCLOSURE
[0008] In one aspect, embodiments disclosed herein relate to a drilling apparatus including a tubular body including an upper connection and a lower connection with a drill bit disposed thereon, and an axial borehole therethrough, wherein the upper connection is configured to attach to a drillstring, primary cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom, backup cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom, and an activation system configured to selectively expand and collapse the primary and backup cutter blocks in response to changes in weight applied to the primary and backup cutter blocks.
[0009] In other aspects, embodiments disclosed herein relate to a method of selectively activating cutter blocks in a drilling apparatus, wherein the drilling apparatus includes a tubular body with an axial borehole therethrough, the method including actuating an activation system, providing fluid communication through an activation port in a main sleeve to a primary cutter block activation port and expanding primary cutter blocks, detecting an increased weight applied to the primary cutter blocks, operating the main sleeve to provide fluid communication to a backup cutter block activation port and expand backup cutter blocks when an increased weight is detected on the primary cutter blocks, and collapsing the primary cutter blocks.
[0010] Other aspects and advantages of the invention will be apparent from the following description and the appended claims.
BRIEF DESCRIPTION OF DRAWINGS
[0011] Figure 1A is a cross-section view of a drilling apparatus in accordance with embodiments of the present disclosure.
[0012] Figure 1B is a cross-section view of components of an activation system in the drilling apparatus in accordance with embodiments of the present disclosure.
[0013] Figure 2A is a cross-section view of a main sleeve of the activation system in the drilling apparatus in a run-in hole condition with primary and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0014] Figure 2B is a cross-section view of the drilling apparatus in a run-in hole condition in accordance with embodiments of the present disclosure.
[0015] Figure 3A is a cross-section view of a main sleeve of the activation system in the drilling apparatus with primary cutter blocks expanded and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0016] Figure 3B is a cross-section view of the drilling apparatus with the primary cutter blocks expanded and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0017] Figure 3C is an operation sequence of the activation system shown in Figure 3A
in accordance with embodiments of the present disclosure.
[0018] Figure 4A is a cross-section view of a main sleeve of the activation system in the drilling apparatus with backup cutter blocks expanded and primary cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0019] Figure 4B is a cross-section view of the drilling apparatus with the backup cutter blocks expanded and primary cutter blocks collapsed in accordance with embodiments of the present disclosure.
[0020] Figure 4C is an operation sequence of the activation system shown in Figure 4A
in accordance with embodiments of the present disclosure.
[0021] Figure 5A is a cross-section view of a main sleeve of the activation system in the drilling apparatus with primary cutter blocks returned to an expanded position and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[00221 Figure 5B is a cross-section view of the drilling apparatus with the primary cutter blocks returned to an expanded position and backup cutter blocks collapsed in accordance with embodiments of the present disclosure.
[00231 Figure 5C is an operation sequence of the activation system shown in Figure 5A
in accordance with embodiments of the present disclosure.
DETAILED DESCRIPTION
[00241 In one aspect, embodiments disclosed herein relate to an activation system and related methods used in a drilling apparatus to selectively open and close expandable cutter blocks of the drilling apparatus. In particular, embodiments disclosed herein relate to methods and apparatus capable of selectively actuating primary and backup cutter blocks during downhole borehole enlarging operations.
[00251 Referring to Figure 1 A, a cross-section view of a drilling apparatus 100 is shown in accordance with embodiments of the present disclosure.j Drilling apparatus includes a drillstring 110 having a drill bit 120 disposed on an ICnd thereof, which drills a pilot hole 111. Drilling apparatus 100 further includes primary cutter blocks 130 and backup cutter blocks 132, which are configured to drill an enlarged borehole 112 along the same path as the pilot hole 111. The cutter blocks are well known in the art and typically include cutting elements and a stabilizer pad (not sown). The primary and ~
backup cutter blocks are configured to travel along grooves (riot shown) formed in the body of the drilling apparatus 100 when expanded or collapsed.]
[00261 The backup cutter blocks 132 may be constructed to'be heavier duty than the primary cutter blocks 130 to withstand cutting in harder formations, and thereby handle more weight. In particular, the backup cutter blocks may be m~re robust by adding extra rows of cutters, using larger size cutters, using more robust cutting materials, varying the cutter shape, or other methods known to those skilled in thei art. Further, the backup cutter blocks may be devoid of cutters for "backreaming," or uiiderreaming while pulling the drilling apparatus out of the wellbore. As such, the backups cutter blocks 132 may be smaller than the primary cutter blocks 130. Embodiments of th'e present disclosure relate
6 to an activation system within drilling apparatus 100 that allows primary cutter blocks 130 and backup cutter blocks 132 to be selectively activated 1ownhole depending upon the characteristics of the formation being drilled.
[0027] Referring now to Figure 1 B, a schematic view of an upper portion of an activation system 200 in the drilling apparatus is shown in accordance, with embodiments of the present disclosure. Activation system 200 includes a pump 219that is coupled to a motor 209 in the drilling apparatus. Pump 210 uses fluid stored in ai reservoir 211 to operate a main sleeve 204 in upward and direction directions. A toggle witch 214 may be used to route fluid to a sleeve activation-down port 222 and a sleeve 4ctivation-up port 223. As used herein, the toggle switch may be defined as a valve to co~ntrol the direction of fluid from the pump either to the sleeve activation-down port 222 or the sleeve activation-up port 223. Toggle switch 214 may be electronically connected to pump 210 and configured to toggle each time pump 210 is stopped. Furthe}; the various components (e.g., pump 210, motor 209, fluid reservoir 211, and toggle sw~tch 214) maybe disposed in a wall of the main body of the drilling apparatus at a location substantially proximate main sleeve 204. Those skilled in the art will understand any umber of electric pumps may be used. For example, in select embodiments, a pump supplied by Bieri Swiss Hydraulics may be used. Further, in select embodiments, a DC motor supplied by MicroMo Electronics may be used; however, those skilled in the art will understand any number of electric motors may be suitable. Depending on the direction in which the fluid is routed, main sleeve 204 having an activation port 208 may be operated, the position of which determines which cutter blocks (primary or backup) are expanded. The following figures illustrate the sequence of operation of actuating the primary and backup cutter blocks while downhole.
100281 Referring now to Figure 2A and 2B, cross-section views of of activation system 200 of the drilling apparatus 100 in a "run-in hole" condition' are shown in accordance with embodiments of the present disclosure. As previously shown in Figure 1 B, activation system 200 includes activation ports 222 and 223 which receive fluid from the reservoir 211 through pump 210 (Figure I B) to operate main sleeve 204. Sleeve activation-down port 222 provides fluid to move main sleeve 204 in a downward
[0027] Referring now to Figure 1 B, a schematic view of an upper portion of an activation system 200 in the drilling apparatus is shown in accordance, with embodiments of the present disclosure. Activation system 200 includes a pump 219that is coupled to a motor 209 in the drilling apparatus. Pump 210 uses fluid stored in ai reservoir 211 to operate a main sleeve 204 in upward and direction directions. A toggle witch 214 may be used to route fluid to a sleeve activation-down port 222 and a sleeve 4ctivation-up port 223. As used herein, the toggle switch may be defined as a valve to co~ntrol the direction of fluid from the pump either to the sleeve activation-down port 222 or the sleeve activation-up port 223. Toggle switch 214 may be electronically connected to pump 210 and configured to toggle each time pump 210 is stopped. Furthe}; the various components (e.g., pump 210, motor 209, fluid reservoir 211, and toggle sw~tch 214) maybe disposed in a wall of the main body of the drilling apparatus at a location substantially proximate main sleeve 204. Those skilled in the art will understand any umber of electric pumps may be used. For example, in select embodiments, a pump supplied by Bieri Swiss Hydraulics may be used. Further, in select embodiments, a DC motor supplied by MicroMo Electronics may be used; however, those skilled in the art will understand any number of electric motors may be suitable. Depending on the direction in which the fluid is routed, main sleeve 204 having an activation port 208 may be operated, the position of which determines which cutter blocks (primary or backup) are expanded. The following figures illustrate the sequence of operation of actuating the primary and backup cutter blocks while downhole.
100281 Referring now to Figure 2A and 2B, cross-section views of of activation system 200 of the drilling apparatus 100 in a "run-in hole" condition' are shown in accordance with embodiments of the present disclosure. As previously shown in Figure 1 B, activation system 200 includes activation ports 222 and 223 which receive fluid from the reservoir 211 through pump 210 (Figure I B) to operate main sleeve 204. Sleeve activation-down port 222 provides fluid to move main sleeve 204 in a downward
7 direction, while sleeve activation-up port 223 provides fluid to move main sleeve 204 in an upward direction. Activation system 200 also includes primary cutter block activation port 230 (to expand primary cutter block) and backup cutter block activation port 232 (to expand backup cutter block). Main sleeve 204 includes a main sleeve activation port 208 configured to align with primary cutter activation port ''230 and a ball-drop sleeve activation port 207 in a ball-drop sleeve 203. Ball-drop sleeve 203 is disposed radially inward of main sleeve 204. As shown, the drilling apparatus may be configured in a run-in hole condition in which the main sleeve activation port 208 and ball-drop sleeve activation port 207 are not aligned, thus the primary cutter block activation port 230 is closed. Further, the backup cutter block activation port 232 is covered by the main sleeve 204, and thus, is also closed. Therefore, both primary and backup cutter blocks are in a retracted position as the drilling apparatus is inserted into the. borehole and run downhole, as shown in Figure 2B.
[0029] Referring to Figures 3A and 3B, cross-section views of activation system 200 of the drilling apparatus are shown in which the activation system 200 is configured to expand the primary cutter blocks 130 (Figure 3B) in accorda$ce~ with embodiments of the present disclosure. Initially, shear pins (not shown), which flxe$ the ball-drop sleeve 203 and the main sleeve 204 relative to each other, are sheared due to an increased hydraulic pressure after a ball drop to move the ball-drop sleeve 203 d~wnward and align ball-drop activation port 207 with main sleeve activation port 208. ! Ba11-drop devices are well known in the art and will not be described in detail. Once: !the ball-drop activation port 207 and the main sleeve activation port 208 are aligned, uid is able to flow into the primary cutter block activation port 230 and expand primary cutter blocks 130, as shown in Figure 3B.
[0030] Figure 3C shows an operation sequence of the activation system 200 shown in Figures 3A and 3B in accordance with embodiments of the present disclosure.
When the pilot hole is drilled and the borehole is to be enlarged, the primary cutter blocks are activated by a ball-drop device 323. The main sleeve is initially in an "up"
position in the bore 326, therefore as described above, when after the ball ;drop device shears the shear pins, activation ports in the ball drop sleeve and the main sleeve are aligned. This allows
[0029] Referring to Figures 3A and 3B, cross-section views of activation system 200 of the drilling apparatus are shown in which the activation system 200 is configured to expand the primary cutter blocks 130 (Figure 3B) in accorda$ce~ with embodiments of the present disclosure. Initially, shear pins (not shown), which flxe$ the ball-drop sleeve 203 and the main sleeve 204 relative to each other, are sheared due to an increased hydraulic pressure after a ball drop to move the ball-drop sleeve 203 d~wnward and align ball-drop activation port 207 with main sleeve activation port 208. ! Ba11-drop devices are well known in the art and will not be described in detail. Once: !the ball-drop activation port 207 and the main sleeve activation port 208 are aligned, uid is able to flow into the primary cutter block activation port 230 and expand primary cutter blocks 130, as shown in Figure 3B.
[0030] Figure 3C shows an operation sequence of the activation system 200 shown in Figures 3A and 3B in accordance with embodiments of the present disclosure.
When the pilot hole is drilled and the borehole is to be enlarged, the primary cutter blocks are activated by a ball-drop device 323. The main sleeve is initially in an "up"
position in the bore 326, therefore as described above, when after the ball ;drop device shears the shear pins, activation ports in the ball drop sleeve and the main sleeve are aligned. This allows
8 the primary cutter blocks to expand, while the backup cutter blocks remain collapsed.
The motor and pump remain off initially 324, 328. The drilling operation continues with the primary cutter block activation port open 330 and the primary cutter blocks expanded 332 to enlarge the borehole.
[00311 While enlarging the borehole, weight sensors (not shown) of the activation system monitor the weight applied on the primary cutter blocks. To reduce premature wear on the primary cutter blocks, the backup cutter blocks may be expanded and the primary cutter blocks collapsed when the drilling apparatus enters a harder formation.
The weight sensors may detect an increased weight applied on the primary cutter blocks and send a signal to operate the activation system by turning on the pump and moving the main sleeve. Normal underreaming operations, for the purposes of embodiments disclosed herein, are typically run with weight on the primary cutter blocks that is about 20-25% of the weight on bit ("WOB"). In embodiments disclosed herein, the weight sensor (e.g., a load cell) may detect a weight applied to the primary cutter'blocks of at least about 35%
WOB before the system is activated and the backup cutter blocks are expanded.
One of ordinary skill in the art will appreciate that other preset limits may be used in accordance with embodiments of the present disclosure. Operation of the activation after the preset weight limit is reached proceeds as follows.
[00321 Referring now to Figures 4A and 4B, cross-section views of activation system 200 of the drilling apparatus are shown in which the activation system 200 is configured to expand backup cutter blocks 132 and retract primary cutter blocks 130 in accordance with embodiments of the present disclosure. Main sleeve 204 is moved in a downward direction by providing fluid through sleeve activation-down port 222 and evacuating fluid from sleeve activation-up port 223. Moving the main sleeve 204 downward covers and seals the primary cutter block activation port 230, which collapses the primary cutter blocks (130 in Figure 4B), and exposes the backup cutter !;block activation port 232 to allow fluid to enter and expand the backup cutter blocks 132;
[00331 Figure 4C shows an operation sequence of the actuation system 200 shown in Figures 4A and 4B in accordance with embodiments of the, present disclosure.
When a
The motor and pump remain off initially 324, 328. The drilling operation continues with the primary cutter block activation port open 330 and the primary cutter blocks expanded 332 to enlarge the borehole.
[00311 While enlarging the borehole, weight sensors (not shown) of the activation system monitor the weight applied on the primary cutter blocks. To reduce premature wear on the primary cutter blocks, the backup cutter blocks may be expanded and the primary cutter blocks collapsed when the drilling apparatus enters a harder formation.
The weight sensors may detect an increased weight applied on the primary cutter blocks and send a signal to operate the activation system by turning on the pump and moving the main sleeve. Normal underreaming operations, for the purposes of embodiments disclosed herein, are typically run with weight on the primary cutter blocks that is about 20-25% of the weight on bit ("WOB"). In embodiments disclosed herein, the weight sensor (e.g., a load cell) may detect a weight applied to the primary cutter'blocks of at least about 35%
WOB before the system is activated and the backup cutter blocks are expanded.
One of ordinary skill in the art will appreciate that other preset limits may be used in accordance with embodiments of the present disclosure. Operation of the activation after the preset weight limit is reached proceeds as follows.
[00321 Referring now to Figures 4A and 4B, cross-section views of activation system 200 of the drilling apparatus are shown in which the activation system 200 is configured to expand backup cutter blocks 132 and retract primary cutter blocks 130 in accordance with embodiments of the present disclosure. Main sleeve 204 is moved in a downward direction by providing fluid through sleeve activation-down port 222 and evacuating fluid from sleeve activation-up port 223. Moving the main sleeve 204 downward covers and seals the primary cutter block activation port 230, which collapses the primary cutter blocks (130 in Figure 4B), and exposes the backup cutter !;block activation port 232 to allow fluid to enter and expand the backup cutter blocks 132;
[00331 Figure 4C shows an operation sequence of the actuation system 200 shown in Figures 4A and 4B in accordance with embodiments of the, present disclosure.
When a
9 weight sensor in the primary cutter blocks detects an increased weight above a preset limit 322 (which indicates the cutter blocks are in a harder formation), the coupled motor and pump may be turned on 324 to activate the main sleeve. The main sleeve is moved downward 326 to expand the backup cutter blocks (by exp sing the backup cutter block activation port 232 of Figure 4A). The coupled motor and pump may be turned off 328 and the drilling operation may continue with the backup cutter block activation port open (primary cutter block activation port closed) 330 and the backup cutter blocks expanded while the primary cutter blocks are collapsed 332.
[0034] While operating with the backup cutter blocks exP~ded, a second weight sensor disposed on or near the backup cutter blocks may monitor the weight applied to the backup cutter blocks. Upon sensing that the weight on the backup cutter blocks has decreased below the prescribed limit (e.g., the weight on the backup cutters is less than 35% WOB), the activation system may be activated to collapse the backup cutter blocks 132 and expand the primary cutter blocks and continue the operation.
[0035] Referring to Figures 5A and 5B, cross-section views of activation system 200 of the drilling apparatus are shown in which the activation system 200 is configured to expand the primary cutter blocks and collapse the backup cutter blocks in accordance with embodiments of the present disclosure. Main sleeve 204 is moved in an upward direction by providing fluid through sleeve activation-up port 223 and evacuating fluid from sleeve activation-down port 222. Moving the main sleeve 204 upward covers and seals the backup cutter block activation port 232, which collapses the backup cutter blocks 132 (Figure 5B), and aligns the ball-drop and main sleeve activation ports 207, 208, respectively, with the primary cutter block activation port 230, which expands the primary cutter blocks 130 (Figure 5B).
[0036] Figure 5C shows an operation sequence of the activation system shown in Figure 5A and 5B in accordance with embodiments of the present disclosure. When the weight sensor disposed on the backup cutter blocks detects a decreased weight below the preset weight limit 322, a signal may be sent to operate the coupled motor and pump 324 and move the main sleeve upward 326 to collapse the backup cutter blocks and expand the primary cutter blocks. After the main sleeve is moved fully upward, the coupled motor and pump are shut off 328 and the drilling operation continues with the primary cutter block activation port open (backup cutter block activation port closed) 330 and the primary cutter blocks expanded while the backup cutter blocks are collapsed 332.
[0037] Advantageously, embodiments of the present disclosure may provide a drilling apparatus capable of adapting to real-time information provided by the weight sensors as to the hardness of the formation. As previously described, prior art cutter blocks require that formation intervals with a particularly increased hardness be identified before beginning the drilling operation. This can be characterized as an "open loop"
system because the initial formation data is the only information available once drilling starts.
Open loop systems are hindered by a change in plans (i.e., drilling in a direction not previously foreseen) and are unable to adapt on the fly. These limitations add considerable cost to the operation both in prep-work prior to drilling and in contingency costs if the drilling operation deviates from the original plan.
[0038] In contrast, the embodiments disclosed herein provide a closed loop system that continuously receives feedback on the current properties of the formation (i.e., the formation hardness) as drilling progresses. This eliminates the need for a preliminary "mapping" operation to find intervals with increased hardness. Additionally, a deviation in the drilling operation is easily accommodated because of the closed loop system's ability to provide feedback on the most current formation conditions. Costs may be drastically reduced and conveyed to the customer.
[0039] Further, embodiments disclosed herein provide a drilling apparatus capable of maintaining a more constant rate of penetration ("ROP") regardless of the hardness of the material through which the drilling apparatus is passing. With only one set of cutter blocks, often the ROP must be decreased in harder material to reduce premature wear of the cutters. In contrast, embodiments disclosed herein provide heavy duty backup cutter blocks to be used in harder formations, thereby allowing the ROP to be maintained. This leads to faster and more efficient drilling and underreaming operations, saving the customer valuable money and rig time.
[0040] Moreover, embodiments of the present disclosure allow the bit and the cutter blocks to be used comparatively for the same length of time. It may be detrimental to have one component (i.e., the bit) outlast the other component (i.e., the cutter blocks) because then the drilling apparatus must be "tripped out" of the wellbore more often to replace parts. However, embodiments disclosed herein substantially reduce the chance that the bit will outlive the cutter blocks, thereby reducing tripping costs.
Finally, embodiments disclosed herein provide redundancy to the drilling apparatus, which is beneficial to reduce costs (i.e., if the primary cutter blocks fail, the backup cutter blocks may be used to complete the job thereby reducing the amount of tripping).
[0041] While the present disclosure has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments may be devised which do not depart from the scope of the disclosure as described herein. Accordingly, the scope of the disclosure should be limited only by the attached claims.
[0034] While operating with the backup cutter blocks exP~ded, a second weight sensor disposed on or near the backup cutter blocks may monitor the weight applied to the backup cutter blocks. Upon sensing that the weight on the backup cutter blocks has decreased below the prescribed limit (e.g., the weight on the backup cutters is less than 35% WOB), the activation system may be activated to collapse the backup cutter blocks 132 and expand the primary cutter blocks and continue the operation.
[0035] Referring to Figures 5A and 5B, cross-section views of activation system 200 of the drilling apparatus are shown in which the activation system 200 is configured to expand the primary cutter blocks and collapse the backup cutter blocks in accordance with embodiments of the present disclosure. Main sleeve 204 is moved in an upward direction by providing fluid through sleeve activation-up port 223 and evacuating fluid from sleeve activation-down port 222. Moving the main sleeve 204 upward covers and seals the backup cutter block activation port 232, which collapses the backup cutter blocks 132 (Figure 5B), and aligns the ball-drop and main sleeve activation ports 207, 208, respectively, with the primary cutter block activation port 230, which expands the primary cutter blocks 130 (Figure 5B).
[0036] Figure 5C shows an operation sequence of the activation system shown in Figure 5A and 5B in accordance with embodiments of the present disclosure. When the weight sensor disposed on the backup cutter blocks detects a decreased weight below the preset weight limit 322, a signal may be sent to operate the coupled motor and pump 324 and move the main sleeve upward 326 to collapse the backup cutter blocks and expand the primary cutter blocks. After the main sleeve is moved fully upward, the coupled motor and pump are shut off 328 and the drilling operation continues with the primary cutter block activation port open (backup cutter block activation port closed) 330 and the primary cutter blocks expanded while the backup cutter blocks are collapsed 332.
[0037] Advantageously, embodiments of the present disclosure may provide a drilling apparatus capable of adapting to real-time information provided by the weight sensors as to the hardness of the formation. As previously described, prior art cutter blocks require that formation intervals with a particularly increased hardness be identified before beginning the drilling operation. This can be characterized as an "open loop"
system because the initial formation data is the only information available once drilling starts.
Open loop systems are hindered by a change in plans (i.e., drilling in a direction not previously foreseen) and are unable to adapt on the fly. These limitations add considerable cost to the operation both in prep-work prior to drilling and in contingency costs if the drilling operation deviates from the original plan.
[0038] In contrast, the embodiments disclosed herein provide a closed loop system that continuously receives feedback on the current properties of the formation (i.e., the formation hardness) as drilling progresses. This eliminates the need for a preliminary "mapping" operation to find intervals with increased hardness. Additionally, a deviation in the drilling operation is easily accommodated because of the closed loop system's ability to provide feedback on the most current formation conditions. Costs may be drastically reduced and conveyed to the customer.
[0039] Further, embodiments disclosed herein provide a drilling apparatus capable of maintaining a more constant rate of penetration ("ROP") regardless of the hardness of the material through which the drilling apparatus is passing. With only one set of cutter blocks, often the ROP must be decreased in harder material to reduce premature wear of the cutters. In contrast, embodiments disclosed herein provide heavy duty backup cutter blocks to be used in harder formations, thereby allowing the ROP to be maintained. This leads to faster and more efficient drilling and underreaming operations, saving the customer valuable money and rig time.
[0040] Moreover, embodiments of the present disclosure allow the bit and the cutter blocks to be used comparatively for the same length of time. It may be detrimental to have one component (i.e., the bit) outlast the other component (i.e., the cutter blocks) because then the drilling apparatus must be "tripped out" of the wellbore more often to replace parts. However, embodiments disclosed herein substantially reduce the chance that the bit will outlive the cutter blocks, thereby reducing tripping costs.
Finally, embodiments disclosed herein provide redundancy to the drilling apparatus, which is beneficial to reduce costs (i.e., if the primary cutter blocks fail, the backup cutter blocks may be used to complete the job thereby reducing the amount of tripping).
[0041] While the present disclosure has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments may be devised which do not depart from the scope of the disclosure as described herein. Accordingly, the scope of the disclosure should be limited only by the attached claims.
Claims (17)
1. A drilling apparatus comprising:
a tubular body comprising an upper connection and a lower connection with a drill bit disposed thereon, and an axial borehole therethrough, wherein the upper connection is configured to attach to a drillstring;
primary cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom;
backup cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom; and an activation system configured to selectively expand and collapse the primary and backup cutter blocks in response to changes in weight applied to the primary and backup cutter blocks.
a tubular body comprising an upper connection and a lower connection with a drill bit disposed thereon, and an axial borehole therethrough, wherein the upper connection is configured to attach to a drillstring;
primary cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom;
backup cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom; and an activation system configured to selectively expand and collapse the primary and backup cutter blocks in response to changes in weight applied to the primary and backup cutter blocks.
2. The drilling apparatus of claim 1, wherein the activation system comprises:
at least one sensor operatively coupled to a motor;
a pump operatively coupled to the motor;
a ball-drop sleeve fixed relative to a main sleeve with at least one shear pin;
wherein the main sleeve is configured to move within the axial borehole of the drilling apparatus to open and close a primary cutter block activation port and a backup cutter block activation port.
at least one sensor operatively coupled to a motor;
a pump operatively coupled to the motor;
a ball-drop sleeve fixed relative to a main sleeve with at least one shear pin;
wherein the main sleeve is configured to move within the axial borehole of the drilling apparatus to open and close a primary cutter block activation port and a backup cutter block activation port.
3. The drilling apparatus of claim 2, further comprising a toggle switch to reroute fluid to operate the main sleeve.
4. The drilling apparatus of claim 2, wherein a first sensor is configured to detect weight applied to the primary cutter blocks.
5. The drilling apparatus of claim 4, wherein the activation system is configured to expand the backup cutter blocks when the first sensor on the primary cutter blocks detects a weight increase of at least about 35% of a weight on the drill bit.
6. The drilling apparatus of claim 2, wherein a second sensor is configured to detect weight applied to the backup cutter blocks.
7. The drilling apparatus of claim 2, wherein a main sleeve activation port is aligned with a ball-drop sleeve activation port and the primary cutter block activation port to expand the primary cutter blocks.
8. The drilling apparatus of claim 1, wherein a ball drop device actuates the activation system.
9. The drilling apparatus of claim 2, wherein the at least one sensor comprises a load cell.
10. A method of selectively activating cutter blocks in a drilling apparatus, wherein the drilling apparatus comprises a tubular body with an axial borehole therethrough, the method comprising:
actuating an activation system;
providing fluid communication through an activation port in a main sleeve to a primary cutter block activation port and expanding primary cutter blocks;
detecting an increased weight applied to the primary cutter blocks;
operating the main sleeve to provide fluid communication to a backup cutter block activation port and expand backup cutter blocks when an increased weight is detected on the primary cutter blocks; and collapsing the primary cutter blocks.
actuating an activation system;
providing fluid communication through an activation port in a main sleeve to a primary cutter block activation port and expanding primary cutter blocks;
detecting an increased weight applied to the primary cutter blocks;
operating the main sleeve to provide fluid communication to a backup cutter block activation port and expand backup cutter blocks when an increased weight is detected on the primary cutter blocks; and collapsing the primary cutter blocks.
11. The method of claim 10, further comprising:
detecting a reduced weight with a second sensor on the backup cutter blocks;
operating the main sleeve to provide fluid communication to the primary cutter block activation port and expanding primary cutter blocks when a reduced weight on the backup cutter blocks is detected; and collapsing the backup cutter blocks.
detecting a reduced weight with a second sensor on the backup cutter blocks;
operating the main sleeve to provide fluid communication to the primary cutter block activation port and expanding primary cutter blocks when a reduced weight on the backup cutter blocks is detected; and collapsing the backup cutter blocks.
12. The method of claim 11, further comprising reversing a fluid flow with a toggle switch to move the main sleeve.
13. The method of claim 11, further comprising operating the main sleeve in an upward direction to expand the primary cutter blocks by providing fluid through a sleeve activation-up port and evacuating fluid from a sleeve activation-down port.
14. The method of claim 10, wherein the detecting a weight increase comprises detecting a weight increase of at least about 35% of a weight on a bit.
15. The method of claim 10, further comprising dropping a ball into the drilling apparatus to actuate the activation system.
16. The method of claim 10, further comprising moving the main sleeve in a downward direction to expand the backup cutter blocks by providing fluid through a sleeve activation-down port and evacuating fluid from a sleeve activation-up port.
17. The method of claim 10, further comprising turning on a coupled motor and pump to operate the main sleeve.
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| US12/499,674 | 2009-07-08 | ||
| US12/499,674 US8327954B2 (en) | 2008-07-09 | 2009-07-08 | Optimized reaming system based upon weight on tool |
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| CA2708922A1 true CA2708922A1 (en) | 2011-01-08 |
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| CA2708922A Abandoned CA2708922A1 (en) | 2009-07-08 | 2010-06-30 | Optimized reaming system based upon weight on tool |
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| US (2) | US8327954B2 (en) |
| CA (1) | CA2708922A1 (en) |
| GB (1) | GB2471751B (en) |
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-
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-
2010
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- 2010-06-30 CA CA2708922A patent/CA2708922A1/en not_active Abandoned
-
2012
- 2012-12-10 US US13/709,894 patent/US8893826B2/en not_active Expired - Fee Related
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| GB201010946D0 (en) | 2010-08-11 |
| GB2471751A (en) | 2011-01-12 |
| US20100006338A1 (en) | 2010-01-14 |
| US20130098682A1 (en) | 2013-04-25 |
| US8327954B2 (en) | 2012-12-11 |
| US8893826B2 (en) | 2014-11-25 |
| GB2471751B (en) | 2011-10-26 |
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